Positionable and Removable Isolation Device in a Wellbore

ABSTRACT

An assembly for installation into a wellbore that includes a main wellbore and a lateral wellbore branching off the main wellbore is described. The assembly includes a tubular positionable in the main wellbore, where the tubular includes a profile. The assembly further includes an isolation device securably landable in and sealable against the profile device to isolate a region of the main wellbore from a region of the lateral wellbore.

BACKGROUND

This section is intended to provide background information to facilitate a better understanding of the various aspects of the described embodiments. Accordingly, it should be understood that these statements are to be read in this light and not as admissions of prior art.

In an oil and gas well, a subterranean formation penetrated by a wellbore is often fractured or otherwise stimulated in order to enhance hydrocarbon production. Fracturing and stimulation operations typically involve a step of isolating a subterranean formation zone using an isolation device. A zone may include multiple branches each of which may be isolated with a suitable isolation device, to then fracture or produce hydrocarbons from a particular branch. Multiple isolation devices can be strategically located at predetermined intervals to isolate various zones and/or branches of interest. For example, an isolation device may straddle a junction area of the wellbore, i.e., the area where the main wellbore connects with a lateral wellbore, to isolate the lateral wellbore. In some implementations, multiple isolation devices may be placed within the one or more branches for purposes of injection, reentry, or the isolation devices may perform as a controlled production conduit.

Alternative methods to position and set an isolation device in the wellbore may include the use of packers, sleeves, plugs, or lateral conduits. For instance, a tubular or a coil bottom hole assembly (BHA) can be positioned in the wellbore using a packer or a pipe tally can be implemented to provide information used to position the BHA in the wellbore. Additional equipment, such as a drilling rig, may be required to run and retrieve the packer and the other component devices.

BRIEF DESCRIPTION OF THE DRAWINGS

For a detailed description of the embodiments of the invention, reference will now be made to the accompanying drawings in which:

FIG. 1 is an elevation view of a wellbore that includes one or more lateral wellbores extending from a main wellbore, in accordance with one or more embodiments;

FIG. 2 is a perspective view of a wellbore including an isolation device for lateral isolation, in accordance with one or more embodiments;

FIG. 3 is a perspective view of a wellbore including an isolation device for main wellbore isolation with closely spaced lateral wellbores, in accordance with one or more embodiments;

FIG. 4 is a perspective view of a wellbore including an isolation device for main wellbore isolation with substantially spaced lateral wellbores, in accordance with one or more embodiments;

FIGS. 5A is a perspective view of an example of a setting component used to install an isolation device in a wellbore, in accordance with one or more embodiments;

FIG. 5B is a perspective view of another example of a setting component passing through an isolation device to relocate further into a wellbore, in accordance with one or more embodiments;

FIG. 6 is a perspective view of a setting component to remove or re-position an isolation device in a wellbore, in accordance with one or more embodiments; and

FIG. 7 is a perspective view of a setting component and a diverter to install, re-position, or remove an isolation device from a wellbore, in accordance with one or more embodiments.

DETAILED DESCRIPTION

This disclosure describes a system and method for positioning an isolation device within a location of a wellbore to isolate one or more wellbore branches from one or more subterranean formation zones. For example, an installed isolation device in a wellbore branch of a first formation zone can isolate formation zone fluids by preventing the fluids from flowing into other branches or zones. The isolation device may be anchored and sealed within a tubular of the wellbore branch, such as a casing or liner, to provide isolation integrity and limit movement of the surrounding formation. In the embodiments, a profile device is integrated into the tubular and used to land and anchor the isolation device in a location and position for purposes of carrying out various operations, including injection programs, stimulation programs, and logging operations, among others.

FIG. 1 is an elevation view of a wellbore 100 that includes one or more lateral wellbores 106 and 109 extending from a main wellbore 102. The wellbore 100 may include a vertical wellbore, such as the main wellbore 102, with multiple laterals wellbores, such as lateral wellbores 106 and 109, and sub-lateral branches (not shown). While various complex configurations for a wellbore may occur, the wellbore 100 of FIG. 1 illustrates a general configuration that includes the main wellbore 102, the lateral wellbores 106 and 109, and a junction area 103 formed in a subterranean formation 104. The junction area 103, as described, includes the point where the lateral wellbore 106 connects with the main wellbore 102.

The lateral wellbore 106 is supported with a downhole tubular or liner, such as a cemented liner 108, to provide support for the insertion of downhole tools. Other lateral wellbores may be unsupported (i.e., openhole without a downhole tubular or liner), such as the lateral wellbore 109. In some cases, a liner may terminate at the junction area 103, like the liner 108 of FIG. 1, or the liner may terminate short of the junction area 103 before reaching the main wellbore 102. Other liner configurations may include, for example, a liner in a main wellbore that terminates before entering a lateral wellbore, a liner laying in an openhole, or a liner with a series of anchors with or without a series of sleeves. In some examples, a window 111 (e.g., milled or pre-milled) may be formed in a side of a tubular or casing 110 of the main wellbore 102 for the creation of the upper lateral wellbore 106 and the insertion of various downhole tools. It should be understood that the main wellbore 102 and other parts of the wellbore 100 may be lined with a tubular for varied purposes including, but not limited to, preventing contamination, supporting formations, or isolating formations within the wellbore 100.

The wellbore 100 can include a profile device 112 to position, anchor, and/or seal a downhole component in the wellbore 100. For example, the profile device 112 may include notches, teeth, grooves, cavities, or other mechanisms to securely grip and land a downhole component, such as an isolation sleeve. The profile device 112 may be a self-orienting device to adjust with relationship to the surrounding environment. In embodiments, one or more sealing devices 114 and/or receptacles 116 may be used with the profile device 112 to add further support and to securely seal the downhole component in the wellbore 100. The sealing device 114 and the receptacle 116 may be disposed around an inner wall of the wellbore 100 to provide a sealed engagement with the downhole component. The profile device 112 and the sealing device 114 could be located in various areas of the wellbore 100 where the profile device 112 can be located within the wellbore 100 and/or the casing 110. The geometric shape or size and the material used to create the profile device 112 and the sealing device 114 may vary depending upon factors known in the art such as the weight of the downhole component and the level of support provided by a casing liner. The receptacle 116 may include a sealing bore, other profile devices, or an expansion device.

FIG. 2 is a perspective view of a wellbore 200 including an isolation device 202 for lateral isolation, in accordance with one or more embodiments. In particular, the wellbore 200 includes a main wellbore 204 and one or more lateral wellbores, including lateral wellbores 206 and 209. As illustrated, the isolation device 202 is positioned in the wellbore 200 to straddle from the main wellbore 204 into the lateral wellbore 206. In this configuration, the isolation device 202 isolates the area of the wellbore 200 located in the main wellbore 204 below the portion of the isolation device 202. Additionally, the isolation device 202 isolates the area where the lateral wellbore 206 and the main wellbore 204 connect, i.e., a junction region 203. The isolation device 202 may not be limited to lateral wellbores extending from the main wellbore 204 but can be located within windows or secondary lateral wellbores formed from the primary lateral wellbores, 206 and 209. Although the isolation device 202 is securely landed and sealed within the wellbore 200, the isolation device 202 may be removed, as will be further discussed. In one or more embodiments, the isolation device 202 can include a sleeve, a plug, a diverter, or any other subsurface isolation device to isolate fluids flowing in the wellbore 200.

In the configuration of FIG. 2, the wellbore 200 can include one or more profile devices installed as an integrated part of a casing 210 and at a pre-determined location within the wellbore 200, including above a window 211 formed in the casing 210. A first profile device 212 is located in the main wellbore 204 and above the lateral wellbore 206, and thus, above the junction region 203. A top portion of the isolation device 202 is configured to land within the first profile device 212. For example, a notch, key, dog, or a landing shoulder formed on an outer surface of the isolation device 202 may be configured to land and securely set within a notch formed in the first profile device 212. The first profile device 212 includes a sealing device 214 configured as a separate or a single integral device. The sealing device 214 further reinforces and supports the positioning and anchoring of the isolation device 202. A second profile device 215 is included in the casing 210 below the junction region 203 to be used with or without an additional sealing device 214. Accordingly, the profile devices 212, 215 can be located above the junction region 203, below the junction region 203, and both above and below the junction region 203. In other embodiments, one or more profile devices may be located in the lateral wellbores 206 and 209.

One or more receptacles 216 can be used as a sealing mechanism to securely seal the isolation device 202 within in the wellbore 200. Specifically, as shown in FIG. 2, a receptacle 216 is located in the lateral wellbore 206 to land and seal a bottom portion of the isolation device 202. The receptacle 216 may be a profile device, as previously described, with or without a sealing device 214. The lateral wellbore 206 includes a cemented liner 220 to support the lateral wellbore 206 and the junction area 203 and the isolation device 202. In other embodiments, the lateral wellbore 206 may be unsupported in an openhole configuration, i.e., no tubular within the borehole.

The profile device 212, in combination with the sealing device 214 and the receptacle 216, securely lands and seals the isolation device 202 within the wellbore 200. Instead of randomly positioning the isolation device 202 or using additional equipment to install the isolation device 202 in the wellbore 200, the first profile device 212 allows positioning and installation of the isolation device 202 in a predetermined location. Further, the profile device 212 can provide positive and repetitive depth, as well as, azimuth correlation to prevent misalignment and/or incorrect positioning of the isolation device 202. Accordingly, injection programs, stimulation programs, large diameter tool passage, high volume production, and logging operations, among other events, can be performed in one or more areas of the wellbore 200 while protecting and isolating other areas. For example, the junction area 203 can be isolated and protected from production flow, injection flow, and stimulation operations that are typically associated with high pressures and erosive materials in a downhole environment.

While one configuration of the isolation device 202 in the wellbore 200 is shown and described in FIG. 2, the number and types of components utilized in the wellbore 200 and different configurations of the isolation device 202 may vary in conjunction with one or more embodiments of the present disclosure. For example, the number or sealing devices and profile devices integrated within the wellbore 200 may vary depending on the type of isolation desired. Further, the profile devices 212 and 215 can accommodate other subsurface devices outside of isolation devices including, but not limited to, diverters, flow control devices, metering devices, logging tool, and monitoring devices.

FIG. 3 is a perspective view of a wellbore including an isolation device for main wellbore isolation with closely spaced lateral wellbores, in accordance with one or more embodiments. The arrangement of FIG. 3 illustrates an upper profile device 312 as a component of a casing 310 and positioned above a junction area 303, as well as, a sealing device 314 located integral to the upper profile device 312. To isolate any one branch of the wellbore 300, an upper portion of an isolation device 302 is positioned and landed in the profile device 312 with the sealing device 314 providing reinforced support of the isolation device 302. As shown in the embodiment of FIG. 3, a liner, such as a receptacle liner 316, terminates before reaching the junction area 303. In this case, part of the lateral wellbore 306 is openhole, or unsupported with a liner.

In some configurations, an insignificant measured distance 317 is formed between an upper lateral wellbore 306 and a lower lateral wellbore 309. As illustrated in FIG. 3, a lower portion of the isolation device 302 is sealed into the receptacle 316 located below the junction area 303. The use of the receptacle 316 can eliminate the need for additional profile devices, for example, a profile device 315 positioned below the junction area 303. Using the upper profile device 312, the isolation device 302 can be positioned in an exact position of a main wellbore 304 to isolate the entire upper lateral wellbore 306 and the junction region 303.

The use of a wellbore tubular or liner with a profile device, as illustrated in the embodiments, eliminates the need for additional sealing components in the wellbore, for instance, packers. When landed and secured in the profile device 312, an internal diameter of the isolation device 302 conforms to the internal diameter of the wellbore 300. The profile device 312 with the isolation device 302 uses a limited amount of wall space or radial space within the wellbore 300 to provide an optimized wellbore passageway. Thus, the isolation device 302 embodies an optimal flow area for a greater fluid flow capacity and for the passage of larger downhole tools and devices. Moreover, by using the profile device 312 in the wellbore 300 to land and anchor the isolation device 302, additional attempts to land the isolation device 302 in the exact location as carried out in a previous landing can be repeated in a repetitive and controlled manner without incident.

FIG. 4 is a perspective view of a wellbore 400 including an isolation device 402 for main wellbore isolation with substantially spaced lateral wellbores, in accordance with one or more embodiments. Similar to the arrangement of FIG. 3, an upper lateral wellbore 406 and a junction area 403 can be isolated from a main wellbore 404 where an isolation device 402 is landed across the junction area 403. In one or more embodiments, an upper profile device 412, as an integrated component of a casing 410, and a sealing device 414 are positioned above the junction area 403 to land and position a top portion of the isolation device 402 in the wellbore 400. In particular, use of the upper profile device 412 lands the upper portion of the isolation device 402 in a predetermined location without the use of additional passage-restricting equipment. The sealing device 414 may reinforce the location and position of the isolation device 402 by providing an additional sealing mechanism.

In the embodiments, a second profile device 415 is disposed below the junction area 403 to eliminate placement of a receptacle (as shown in FIG. 3 at 316) or any other lengthy seal mechanisms that may extend into the lower lateral wellbore 409. The second profile device 415 is positioned and sealed in the lower portion of the isolation device 402 in a location of the main wellbore 404. Accordingly, the second profile device 415 can reduce the need, and thus cost for, additional pipe sections within the wellbore 400.

FIGS. 5A is a perspective view of an example of a setting component 504 used to install an isolation device 502 in a wellbore 500, in accordance with one or more embodiments. An isolation device 502 is installed in the wellbore 500 using a setting component 504, for example, coil tubing, pipe tubing, or wirelines, without the use of a rig. Accordingly, the installation and removal, which will be later discussed, of the isolation device 502 can be accomplished by a rigless technique, i.e., without the use of a drilling rig, work-over rig or any other type of pulling unit device.

Connected to the setting component 504 and a running tool 506, the isolation device 502 is lowered into the wellbore 500 until a top portion of the isolation device 502 reaches a first profile device 512. In the embodiments, the isolation device 502 may be positioned in a predetermined location of the wellbore 500 when one or more notches 513 of the device 502 mate with a mechanism of the first profile device 512. Moreover, a lower portion of the isolation device 502 is sealed in a predetermined position using a second profile device 515 with a sealing device 514. To facilitate stimulation operations, an optional stimulation tool 518 can be attached to the setting component 504 and deployed downhole to isolate other areas of the wellbore 500, to inject fluids into a subsurface formation, and to collect measurements, among other operations.

FIG. 5B is a perspective view of another example of a setting component 504 passing through an isolation device 502 to relocate further into a wellbore 500. The setting component 504, including a running tool 506 and an optional stimulation tool 518, can be disconnected from the isolation device 502 to pass through the isolation device 502 and further downhole to carry out various operations including, but not limited to, stimulating, washing, jetting, cleaning, acidizing, and other tasks. Since a casing 510 includes the profile devices 512, 515 and the sealing device 514, the setting component 504, among other downhole equipment and tools, can move through the wellbore 500 with little to no passageway restrictions. In some cases, after accommodating other downhole tools to other points within the wellbore 500 to carry out other operations and remedial tasks, the setting component 504 and the attached components can be re-attached to the isolation device 502. Specifically, the setting component 504 can be re-positioned and re-attached to the isolation device 502 to re-engage and remove the device 502 from the wellbore 500.

FIG. 6 is a perspective view of a setting component 605 to remove or re-position an isolation device 602 from a wellbore 600, in accordance with one or more embodiments. As shown in FIG. 6, the setting component 605 can unlatch and raise the isolation device 602 from a profile device 612 for complete removal or for re-positioning of the isolation device 602 to another area of the wellbore 600. Since a casing 610 includes the profile device 612 and a sealing device 614, the isolation device 602 is removed or re-positioned in the wellbore 600 with little to no passageway restrictions.

FIG. 7 is a perspective view of a setting component 705 and a diverter 703 to install, reposition, or remove an isolation device 702 from a wellbore 700, in accordance with one or more embodiments. The diverter 703 is installed into a lower profile device 715 with the setting tool 705 as described above or by any other known installation methods. The diverter 703 can be attached to and installed along with an isolation device 702 or installed during a separate trip using the setting tool 705.

In the arrangement of FIG. 7, the installed diverter 703 prevents vertical wellbore access and directs the removal, installation, or re-positioning of the isolation device 703 into a lateral wellbore 706. For example, as the isolation device 702 is lowered into a main wellbore 704, the diverter 703 may deflect the isolation device 702 into the lateral wellbore 706. In one or more embodiments, the lower profile device 715 and an upper profile device 712 work in tandem to land the diverter 703 and the isolation device 702, respectively, so that the isolation device 702 is positioned and sealed in a desired position for lateral bore isolation.

Since the profile devices 712, 715 can be included with a casing 710, the isolation device 702 and the diverter 703 may be installed and/or re-positioned to a predetermined location or removed from the wellbore 700 with little to no passageway restrictions. In addition to the diverter 703, other components including, but not limited to, indexing tools and sub-tools may be used to position the isolation device 702 within the wellbore 700.

In addition, to the embodiments described above, many examples of specific combinations are within the scope of the disclosure, some of which are detailed below:

-   Example 1. An assembly for installation into a wellbore comprising a     main wellbore and a lateral wellbore branching off the main     wellbore, the assembly comprising:

a tubular positionable in the main wellbore and comprising a profile device; and an isolation device securably landable in and sealable against the profile device to isolate a region of the main wellbore from a region of the lateral wellbore.

-   Example 2. The assembly of Example 1, wherein the isolation device     is extendable into the lateral wellbore to isolate the lateral     wellbore from a portion of the main wellbore. -   Example 3. The assembly of Example 1 wherein the isolation device is     installable or removable from the tubular without a rig or a pulling     unit device. -   Example 4. The assembly of Example 1, wherein the isolation device     is landable in the main wellbore to isolate the lateral wellbore     from the main wellbore. -   Example 5. The assembly of Example 1, wherein the profile device is     locatable in the main wellbore and positionable above a junction     region, below the junction region, or above and below the junction     region joining the main wellbore and the lateral wellbore. -   Example 6. The assembly of Example 1, wherein the isolation device     is installable or removable from the wellbore using a downhole     install device, wherein the downhole install device is configured     for attachment and re-attachment to the isolation device. -   Example 7. The assembly of Example 1, wherein a sealing device is     locatable in the main wellbore. -   Example 8. The assembly of Example 7, wherein the sealing device is     usable with the profile device to secure the isolation device into     the profile device. -   Example 9. The assembly of claim 1, wherein the profile device     comprises a self-orienting profile configured to rotationally orient     the isolation device as it is landed in the profile device. -   Example 10. A method of isolating a main wellbore from a lateral     wellbore branching off the main wellbore, the method comprising:     -   installing a tubular comprising a profile device in the         wellbore;     -   landing an isolation device into the profile device;     -   sealing the isolation device against the tubular to isolate a         junction region of the wellbore that connects the main wellbore         and the lateral wellbore. -   Example 11. The method of Example 10, further comprising sealing a     first end of the isolation device into a first sealing device at a     location above the junction region. -   Example 12. The method of Example 11, further comprising sealing a     second end of the isolation device into a sealing device in the main     wellbore at a location below the junction region. -   Example 13. The method of Example 10, further comprising extending     the isolation device across the junction region to isolate the     lateral wellbore. -   Example 14. The method of Example 10, further comprising guiding a     second end of the isolation device across the junction region to     isolate a region of the main wellbore and the junction region. -   Example 15. The method of Example 10, further comprising installing     or removing the isolation device from the wellbore using at least     one of a coil tube, a pipe tube, or a wireline, wherein the     isolation device is attached to at least one of the coil tube, the     pipe tube, or the wireline. -   Example 16. The method of Example 10, further comprising positioning     the profile device in the main wellbore above the junction region,     below the junction region, or above and below the junction region. -   Example 17. The method of Example 10, further comprising landing the     isolation device in a sealing device and a profile device below the     junction region. -   Example 18. The method of Example 10, further comprising positioning     a sealing device in the main wellbore based on a distance between a     first lateral wellbore and a second lateral wellbore. -   Example 19. The method of Example 10, further comprising installing     or removing the isolation device without a rig or a pulling unit     device. -   Example 20. The method of Example 10, further comprising     rotationally orienting the isolation device as the isolation device     lands in the profile device.

The previous discussion is directed to various embodiments of the present disclosure. The drawing figures are not necessarily to scale. Certain features of the embodiments may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. Although one or more of these embodiments may be preferred, the embodiments disclosed should not be interpreted, or otherwise used, as limiting the scope of the disclosure, including the claims. It is to be fully recognized that the different teachings of the embodiments discussed below may be employed separately or in any suitable combination to produce desired results. In addition, one skilled in the art will understand that the previous description has broad application, and the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to intimate that the scope of the disclosure, including the claims, is limited to that embodiment.

Certain terms are used throughout the previous description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but are the same structure or function. The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness.

In the previous discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .” Also, the term “couple” or “couples” is intended to mean either an indirect or direct connection. In addition, the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. For instance, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis. The use of “top,” “bottom,” “above,” “below,” and variations of these terms is made for convenience, but does not require any particular orientation of the components.

Reference throughout this specification to “one embodiment,” “an embodiment,” or similar language means that a particular feature, structure, or characteristic described in connection with the embodiment may be included in at least one embodiment of the present disclosure. Thus, appearances of the phrases “in one embodiment,” “in an embodiment,” and similar language throughout this specification may, but do not necessarily, all refer to the same embodiment. Further, the illustrated figures included within are only exemplary and are not intended to assert or imply any limitation with regard to the environment, architecture, design, or process in which different embodiments may be implemented.

While the aspects of the present disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein. But it should be understood that the invention is not intended to be limited to the particular forms disclosed. Rather, the invention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the invention as defined by the following appended claims. 

What is claimed is:
 1. An assembly for installation into a wellbore comprising a main wellbore and a lateral wellbore branching off the main wellbore, the assembly comprising: a tubular positionable in the main wellbore and comprising a profile device; and an isolation device securably landable in and sealable against the profile device to isolate a region of the main wellbore from a region of the lateral wellbore.
 2. The assembly of claim 1, wherein the isolation device is extendable into the lateral wellbore to isolate the lateral wellbore from a portion of the main wellbore.
 3. The assembly of claim 1 wherein the isolation device is installable or removable from the tubular without a rig or a pulling unit device.
 4. The assembly of claim 1, wherein the isolation device is landable in the main wellbore to isolate the lateral wellbore from the main wellbore.
 5. The assembly of claim 1, wherein the profile device is locatable in the main wellbore and positionable above a junction region, below the junction region, or above and below the junction region joining the main wellbore and the lateral wellbore.
 6. The assembly of claim 1, wherein the isolation device is installable or removable from the wellbore using a downhole install device, wherein the downhole install device is configured for attachment and re-attachment to the isolation device.
 7. The assembly of claim 1, wherein a sealing device is locatable in the main wellbore.
 8. The assembly of claim 7, wherein the sealing device is usable with the profile device to secure the isolation device into the profile device.
 9. The assembly of claim 1, wherein the profile device comprises a self-orienting profile configured to rotationally orient the isolation device as it is landed in the profile device.
 10. A method of isolating a main wellbore from a lateral wellbore branching off the main wellbore, the method comprising: installing a tubular comprising a profile device in the wellbore; landing an isolation device into the profile device; sealing the isolation device against the tubular to isolate a junction region of the wellbore that connects the main wellbore and the lateral wellbore.
 11. The method of claim 10, further comprising sealing a first end of the isolation device into a first sealing device at a location above the junction region.
 12. The method of claim 11, further comprising sealing a second end of the isolation device into a sealing device in the main wellbore at a location below the junction region.
 13. The method of claim 10, further comprising extending the isolation device across the junction region to isolate the lateral wellbore.
 14. The method of claim 10, further comprising guiding a second end of the isolation device across the junction region to isolate a region of the main wellbore and the junction region.
 15. The method of claim 10, further comprising installing or removing the isolation device from the wellbore using at least one of a coil tube, a pipe tube, or a wireline, wherein the isolation device is attached to at least one of the coil tube, the pipe tube, or the wireline.
 16. The method of claim 10, further comprising positioning the profile device in the main wellbore above the junction region, below the junction region, or above and below the junction region.
 17. The method of claim 10, further comprising landing the isolation device in a sealing device and a profile device below the junction region.
 18. The method of claim 10, further comprising positioning a sealing device in the main wellbore based on a distance between a first lateral wellbore and a second lateral wellbore.
 19. The method of claim 10, further comprising installing or removing the isolation device without a rig or a pulling unit device.
 20. The method of claim 10, further comprising rotationally orienting the isolation device as the isolation device lands in the profile device. 